GWT2Energy Market Intelligence · September 2026
Monthly Energy Market Outlook
A practical monthly view of U.S. natural gas, regional power markets, capacity pressures, and procurement decisions for multi-site restaurant, retail, and commercial portfolios.
Executive Summary
September 2026 Takeaway
U.S. natural gas enters September with a meaningful inventory cushion, record production, and softer near-term pricing. Lower 48 storage reached 3,184 Bcf for the week ending August 21—about 6% above the five-year average—while EIA expects marketed production to set a record in 2026. That combination limits immediate scarcity risk even as late-summer power burn, returning LNG feedgas demand, and tropical disruptions can still move prompt prices.
Power-market risk remains more regional than national. NOAA’s updated September outlook favors warmer-than-normal conditions across the central United States, Great Lakes, Mid-Atlantic, and much of the southern tier, while parts of the West begin the month cooler and wetter. For multi-site buyers, the most useful posture is to separate a relatively comfortable commodity backdrop from rising capacity, transmission, basis, and utility-delivery costs.
Market Scorecard
What the Market Is Signaling
Comfortable
Storage is roughly 6% above the five-year average and 2026 production is on pace for a record.
Moderate
EIA expects Henry Hub below $3/MMBtu into November, with weather, LNG operations, and tropical activity the main upside risks.
Regionally Warm
Warmer odds favor the central U.S., Great Lakes, Mid-Atlantic, and southern tier, while early-month western conditions are cooler and wetter.
Layer Selectively
Use commodity softness where it improves the risk position, while preserving flexibility for changing store load and regional charges.
Natural Gas Fundamentals
Inventory Cushion Meets a Tighter Weekly Balance
Storage
Lower 48 working gas totaled 3,184 Bcf for the week ending August 21, 2026, following a 15 Bcf injection. Inventories were 167 Bcf, or about 6%, above the 2021–2025 average, but 30 Bcf below the prior year. The latest injection was smaller than the five-year norm, so the surplus is comfortable but not static.
Production
EIA forecasts U.S. marketed natural gas production to average a record 122.5 Bcf/d in 2026, up from 118.5 Bcf/d in 2025. Growth is concentrated in the Permian and Haynesville regions and remains the main buffer against expanding export and power-sector demand.
LNG Exports
EIA expects U.S. LNG exports to average 16.5 Bcf/d in the third quarter. Freeport maintenance reduced feedgas demand during the summer; normalization after maintenance, new export capacity, and higher pipeline exports to Mexico can tighten the balance as autumn approaches.
Forward Market
EIA’s August outlook put the third-quarter Henry Hub average at $2.87/MMBtu and expected prices to remain below $3.00 until November. It also forecast 3,985 Bcf in storage at the end of October, 5% above the five-year average. The curve remains constructive for buyers, but winter and regional basis exposure still require separate review.
Weather & Power Market Fundamentals
September Load Risk Shifts by Region
NOAA’s August 31 update favors above-normal September temperatures across the central United States, Great Lakes, Mid-Atlantic, and much of the southern tier. Cooler early-month weather is expected in parts of the West, while precipitation is favored in the West and Northeast and drier conditions in portions of the central Plains and central Mississippi Valley. This pattern may extend cooling demand in several major commercial-load regions without creating a uniform national peak.
PJM
Data-center growth remains the structural issue. PJM’s 2026 forecast raised long-run summer peak growth to about 2.4% annually, reinforcing the need to evaluate capacity and transmission exposure separately from forward energy prices.
ERCOT
Late-season heat can still pressure reserves, but changing large-load assumptions have reduced some near-term demand expectations. Continue monitoring real-time reserve conditions, local congestion, and the pace of new load connections rather than relying on a single systemwide forecast.
MISO
Growing data-center and industrial demand is raising long-term load expectations as the resource mix changes. Zone-level capacity, transmission, and utility-rate outcomes can diverge materially across a multi-state portfolio.
Southeast
NOAA’s warm September tilt can prolong cooling and refrigeration load. Population and industrial growth, utility capital plans, and rate cases remain as important to delivered cost as fuel prices.
Capacity & Transmission
Delivered-Cost Risk Keeps Rising
Capacity auctions, transmission upgrades, congestion, and distribution investment increasingly shape commercial electricity costs. Map each location to its utility, ISO/RTO zone, peak-setting methodology, and contract treatment so non-commodity charges are visible before renewal.
Monitor peak risk with GridWatch →Procurement Strategy
Use Shoulder-Season Optionality
Review expirations before winter risk premiums build. Layer fixed exposure where the forward market improves budget certainty, but keep flexibility for store openings, closures, operating-hour changes, and locations where basis or regulated delivery charges dominate the bill.
Explore GWT2Energy procurement support →Restaurant & Retail Insights
Turn the September Transition Into Operating Action
Restaurants
Do not relax cooling or refrigeration oversight just because the calendar turns to fall. Warm central and southern conditions can keep coincident HVAC, kitchen, and refrigeration loads elevated; verify schedules, setpoints, door seals, and alarm response.
Retail
Use mixed September weather to compare similar stores under different temperature conditions. Weather-normalized outliers often expose schedule drift, simultaneous heating and cooling, lighting overrides, or billing errors.
Facilities Teams
Reconcile procurement assumptions with interval data before renewal. Confirm holiday-hour templates, winter setpoints, economizer operation, and open equipment issues while shoulder-season conditions make corrective work less disruptive.
GWT2Energy Insight of the Month
Commodity Comfort Is Not the Same as Budget Comfort
September’s gas backdrop is buyer-friendly, but a comfortable national storage number does not guarantee a lower facility bill. Capacity, transmission, basis, tariffs, demand charges, weather, and operating drift can offset a favorable commodity price. The strongest procurement decision connects the contract to the portfolio’s actual load shape and controllable peak behavior.
What We’re Watching Next Month
October Watch List
- End-of-injection-season storage and the pace of the five-year surplus
- LNG feedgas recovery and export-project ramp-up
- Early heating demand and updated winter weather signals
- PJM, ERCOT, and MISO capacity and load developments
- Utility rate cases, transmission charges, and 2027 budget assumptions
Archive
Previous Monthly Reports
September 2026 is the current edition. The first edition, published for August 2026, emphasized above-average storage, near-record production, rising structural demand, and disciplined contract layering.
September 2026 · Current report
August 2026 · Prior report
Market information reviewed through July 31, 2026. The core view was to separate commodity timing from total delivered-cost risk as LNG exports, data centers, electrification, and industrial growth increased long-term demand.
Frequently Asked Questions
About the Monthly Energy Market Outlook
What does the outlook cover?
It covers U.S. natural gas supply and demand, regional power-market conditions, capacity and transmission, procurement implications, and operating considerations for multi-site commercial portfolios.
Is this a price forecast?
No. It is an operating and procurement perspective based on available market information. Forward prices, weather, regulations, utility tariffs, and facility load can change.
How often is it updated?
GWT2Energy publishes the outlook monthly. The weekly page covers shorter-term weather and energy conditions between monthly editions.
How should a company use this information?
Use it to frame questions for procurement, finance, facilities, and operations teams. Contract decisions should be based on the organization’s locations, load shape, risk policy, budget, and current agreements.
This report is general market commentary, not individualized legal, financial, or commodity-trading advice.
Put the Market in Portfolio Context
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